Please reload

Recent Posts

PES | Goal Setting Workshop (CANCELLED)

March 10, 2020

1/10
Please reload

Featured Posts

A Completions Solution That Cost Effectively Transitions From Frac-Flowback to Natural Flow to Artificial Lift

March 1, 2017

Date: Tuesday March 7, 2017
Time: 11:30 - 1:00 pm
Location: Calgary Petroleum Club
For more info refer to this link: https://goo.gl/G837ec

 

Production Plus Energy Services Inc. has learned that the root cause of gas interference and solids damage to pumps, common in horizontal wells, is not poor equipment performance, but sluggy, intermittent production from the horizontal. Large variations in gas and oil rates long with periods of only gas production from the horizontal overwhelm downhole artificial lift pumps. By conditioning the downhole flow, artificial lift pumps can operate efficiently and reliably. 

This presentation reviews the technical basis of slug flow and overviews a downhole flow-conditioning completions system that benefits the frac-flowback phase, extends the natural flow phase and enhances the artificial lift phase. Slug flow mitigation during frac-flowback has the potential to significantly reduce proppant flowback and other solids related issues. Extending the natural flow period has the attractive features of lower OPEX production and lowering the capital cost of the artificial lift system. Mitigating slug flows during the artificial lift phase has the production enhancing benefit of maximizing drawdown over the life of the well while improving reliability of the artificial lift system (reducing workovers). 

Simpler, less costly transitions between production phases reduce total well cost. Case studies will demonstrate that a slug flow mitigation strategy can significantly benefit a well’s NPV (Net Present Value). This is achieved through a combination of increased pump efficiency and increased drawdown that allows the pump to be positioned in vertical inclinations and at shallower depths. Shallower pump placement and smaller artificial lift equipment, can reduce CAPEX and OPEX. As a result smaller pumping equipment can efficiently achieve higher production rates while simultaneously maximizing drawdown and reducing unit lifting costs over the life of the well.

Please reload